US3824766A - Gas purification - Google Patents
Gas purification Download PDFInfo
- Publication number
- US3824766A US3824766A US00359032A US35903273A US3824766A US 3824766 A US3824766 A US 3824766A US 00359032 A US00359032 A US 00359032A US 35903273 A US35903273 A US 35903273A US 3824766 A US3824766 A US 3824766A
- Authority
- US
- United States
- Prior art keywords
- zone
- solvent
- gas
- hydrogen sulfide
- carbon dioxide
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
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- 238000000746 purification Methods 0.000 title claims abstract description 10
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 142
- 239000007789 gas Substances 0.000 claims abstract description 142
- 239000002904 solvent Substances 0.000 claims abstract description 105
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims abstract description 102
- 229910002092 carbon dioxide Inorganic materials 0.000 claims abstract description 71
- 239000001569 carbon dioxide Substances 0.000 claims abstract description 70
- 239000000203 mixture Substances 0.000 claims abstract description 68
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 65
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims abstract description 65
- 238000000034 method Methods 0.000 claims abstract description 27
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 12
- 238000010521 absorption reaction Methods 0.000 claims description 64
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 24
- 230000003750 conditioning effect Effects 0.000 claims description 16
- 238000001816 cooling Methods 0.000 claims description 14
- 239000003345 natural gas Substances 0.000 claims description 14
- 238000003786 synthesis reaction Methods 0.000 claims description 11
- 230000015572 biosynthetic process Effects 0.000 claims description 10
- 230000000694 effects Effects 0.000 claims description 8
- 229920001223 polyethylene glycol Polymers 0.000 claims description 8
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical group C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 claims description 7
- 239000005977 Ethylene Substances 0.000 claims description 7
- 150000005218 dimethyl ethers Chemical class 0.000 claims description 7
- 238000007599 discharging Methods 0.000 claims description 7
- 238000005201 scrubbing Methods 0.000 claims description 5
- 239000002803 fossil fuel Substances 0.000 claims description 3
- 238000010926 purge Methods 0.000 claims description 3
- 239000011261 inert gas Substances 0.000 claims description 2
- 239000007788 liquid Substances 0.000 abstract description 13
- 229920001515 polyalkylene glycol Polymers 0.000 abstract description 6
- 150000001983 dialkylethers Chemical class 0.000 abstract description 5
- 239000006096 absorbing agent Substances 0.000 description 21
- 229910052739 hydrogen Inorganic materials 0.000 description 8
- 239000001257 hydrogen Substances 0.000 description 8
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 7
- 229930195733 hydrocarbon Natural products 0.000 description 7
- 150000002430 hydrocarbons Chemical class 0.000 description 7
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 239000004215 Carbon black (E152) Substances 0.000 description 6
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 6
- 229910002091 carbon monoxide Inorganic materials 0.000 description 6
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 5
- 238000006243 chemical reaction Methods 0.000 description 5
- 239000000470 constituent Substances 0.000 description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 4
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 3
- 125000000217 alkyl group Chemical group 0.000 description 3
- 229910052799 carbon Inorganic materials 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- 238000012856 packing Methods 0.000 description 3
- 239000000047 product Substances 0.000 description 3
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 description 2
- LCGLNKUTAGEVQW-UHFFFAOYSA-N Dimethyl ether Chemical compound COC LCGLNKUTAGEVQW-UHFFFAOYSA-N 0.000 description 2
- 239000002202 Polyethylene glycol Substances 0.000 description 2
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 2
- 239000002253 acid Substances 0.000 description 2
- 125000004432 carbon atom Chemical group C* 0.000 description 2
- 238000010276 construction Methods 0.000 description 2
- 230000001419 dependent effect Effects 0.000 description 2
- 230000009977 dual effect Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 230000000717 retained effect Effects 0.000 description 2
- 238000009738 saturating Methods 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- -1 steam Chemical compound 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000003054 catalyst Substances 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000002950 deficient Effects 0.000 description 1
- 230000001627 detrimental effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- RLQJEEJISHYWON-UHFFFAOYSA-N flonicamid Chemical compound FC(F)(F)C1=CC=NC=C1C(=O)NCC#N RLQJEEJISHYWON-UHFFFAOYSA-N 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 150000002431 hydrogen Chemical class 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 239000002574 poison Substances 0.000 description 1
- 231100000614 poison Toxicity 0.000 description 1
- 229920000573 polyethylene Polymers 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 239000002912 waste gas Substances 0.000 description 1
Images
Classifications
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- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/34—Chemical or biological purification of waste gases
- B01D53/46—Removing components of defined structure
- B01D53/48—Sulfur compounds
- B01D53/52—Hydrogen sulfide
- B01D53/523—Mixtures of hydrogen sulfide and sulfur oxides
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1456—Removing acid components
- B01D53/1462—Removing mixtures of hydrogen sulfide and carbon dioxide
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01D—SEPARATION
- B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
- B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
- B01D53/1493—Selection of liquid materials for use as absorbents
-
- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C7/00—Purification; Separation; Use of additives
- C07C7/11—Purification; Separation; Use of additives by absorption, i.e. purification or separation of gaseous hydrocarbons with the aid of liquids
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
- Y02C20/00—Capture or disposal of greenhouse gases
- Y02C20/40—Capture or disposal of greenhouse gases of CO2
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
- Y02P20/00—Technologies relating to chemical industry
- Y02P20/151—Reduction of greenhouse gas [GHG] emissions, e.g. CO2
Definitions
- ABSTRACT [21] Appl, N0.: 359,032 Adiabatic process for purification of a gas mixture containing principally methane together with carbon I dioxide and minor amounts of hydrogen sulfide to re gg move substantially all the hydrogen sulfide while re.
- This invention relates to the purification of gas and moreparticularly refers to a new and-improved process for purification of a gas mixture containing methane together with carbon dioxide and hydrogen sulfide to remove substantially all the hydrogen sulfide while retaining most of the carbon dioxide in the gas mixture.
- Methanol is produced from synthesis gas, i.e., a gas composition of essentially two parts of hydrogen and. one part carbon monoxide.
- Synthesis gas may be prepared from natural gas by reacting steam with methane to form hydrogen and carbon monoxide as shown in the V equation below:
- agas mixture containing principally methane together with car-. bon dioxide and minor amounts of hydrogen sulfide may be purified to remove substantially all the hydrogen sulfide while retaining most of the carbon dioxide in the gas mixtureby (a) maintaining an'absorption zone under superatmospheric pressure within therange of 400 to 2,000, preferably 500 to 1,500 pounds per square inch absolute, and at a temperature between and 140 F., preferably 70 to 1 10 F.; (b) introducing a gas mixture containing principally methane together with carbon dioxide and minor amounts of hydrogen sulfide into the lower section of the absorption zone; (c) introducing as a solvent medium a normally liquid dialkyl ether of a polyalkylene glycol having 1 8 carbon atoms in each alkyl group and 3 8 ethylene 'units,preferably a dimethylether of a polyethylene glycol, desirably a mixture of dimethylethers of polyethylene glycols, containing dissolved carbon dioxide,
- the rich solvent from the absorption zone isfirst sent to a flashing zone to liberate minor amounts of methane and CO dissolved in the rich solvent, and then the thus diluted solvent passed to the stripping zone for removal of hydrogen sulfide.
- the feed gas is a gas mixture containing usually as a principal constituent methane together with substantial amounts of carbon dioxide and some hydrogen sulfide.
- Natural gas is a good source of feed gas since it contains a high percentage of methane and substantial amounts of carbon dioxide together with minoramounts of hydrogensulfide and in addition, contains, frequently, inerts such as nitrogen as well as small amounts of other constituents such as higher molecular weight hydrocarbons.
- Feed gas may also be derived from fossil fuel such as petroleum, coal and shale.
- the feed gas To make the feed gas suitable for conversion to synthesis gas and subsequently to methyl alcohol, the feed gas must be reduced in hydrogen sulfide content to a very low value of the order of 5 parts per million or less hydrogen sulfide. Removal of hgdrogen sulfide from the feed gas should be accomplished while removing as little carbon dioxide as possible since the carbon dioxide retained in the gas is useful in the conversion of the gas to synthesis gas.
- a feed gas composition is given below:
- Absorber 4 may be anysuitable tower filled with packing, such as Pall ring packing, or perforated plates, preferably valve trays to ensure good contact between liquid and gas in the tower.
- the solvent medium entering the top of absorber 4 through line 6 is a normally lqiuid dialkyle'ther of a polyalkylene glycol, preferably a dialkylether of a polyethylene glycol having 1 8 carbon atoms in each alkyl group and 3 8 ethylene units, desirably the alkyls are methyl and the solvent is a mixture of the dimethylethers of polyethylene glycols.
- the solvent medium contains dissolved carbon dioxide and preferably is saturated with carbon dioxide. Heat is v evolved when carbon dioxide is absorbed in the solvent. Specifically, the heat of absorption of carbon dioxide in the solvent is about 160 BUTs per pound.
- a solvent medium comprising the dialkyl-ether .of polyalkylene glycol containing dissolved carbon dioxide facilitates maintaining a lower temperature in absorption tower 4.
- the sol.- vent medium should not only contain dissolved carbon dioxide but should also be cooled prior to entering the absorption tower 4 to a temperature below the temperature in the tower. In this manner a sharp temperature rise at the top of absorber tower 4 is prevented, as would otherwise occur, and thus provides more efficient hydrogen sulfide absorption.
- the temperature of the tower may vary between about 20 F. and 140 F. and is preferably within the range of about 70 to 110 F.-The temperature at the top of absorber 4 is usually lower than that at the bottom by about 10 to 20. To minimize the differential in temperature between top and bottom and to maintain lower temperature in the absorber tower 4, the feed gas as previously mentioned is preferably cooled prior to entering the tower to a'temperature below that in the tower by passing in indirect heat exchange with the gases leaving the tower in heat exchanger 2.
- Solvent medium isfiintro'duced through line 6 into tower 4 at a rate sufficient to dissolve substantially all the hydrogen sulfide in'the gas entering through lines and passing upward countercurrent to and in intimate contact with the solvent medium,
- the rate of solvent will vary dependent upon the concentration of acid gas and upon the temperature and pressure in the tower. Ordinarily, 0.05 to 10 gallons of solvent medium per standard cubic foot of acid gas will be adequate to re- I move all of the hydrogen sulfide from the feed gas.
- drogen' sulfide hasa solubility in the solvent several times greater than that of carbon dioxide and as will be evident will readily dissolve in the solvent.
- a solvent medium saturated with carbon dioxide and cooled to a temperature below that in the absorption "zone permits a lower solvent circulation rate as physical solvent absorption efficiencies improve with lower-operating temperatures.
- Rich solvent containing substantially all thehy'drogen sulfide from the feed gas together with carbon dioxide and some hydrocarbon methane gas is directed into' flash tank 8 maintained at a reduced pressure'to permit liberation of a minor amount of gas comprising as its principal constituent methane.
- the liberated vapors pass up through flash tank 8, through entrainment knock-out section 9 which may be a plurality of baffles or other media on which the liquid droplets entrained in the gas collect, coalesce and drop back into the liquid body of solvent contained in flash tank 8.
- Normally a pressure in flash tank 8 of about 5 percent to percent of the pressure in absorption tower 4 will permit liberation of the gas containing methane from the rich solvent entering through line 7.
- the gas released from the top of flash tank 8 through line 11 may be discharged from the system and burned as fuel or may be, if desired, returned to absorption column 4 for further recovery. of the hydrocarbon content in the gas.
- stripper column 13 which may be any suitable packed tower or valve tray tower similar in construction to absorber column 4.
- the pressure in stripper column 13 is maintained below that of absorber 4, generally within the range of about 12 to 100 pounds per square inch absolute, preferably under substantially atmospheric pressure, i.e., about 0 to 10 pounds per square inch gauge, and the temperature may vary from a low of about to about 300 F. dependent upon the pressure and. amount of stripping gas, preferably the temperature will be maintained within the range of about to F.
- Stripping gas entering stripper 13 through line 15 may be any inert gas such as nitrogen, air, steam, methane or even waste gases as for example, purge gas from the methanol synthesis plant which contains nitrogen, carbon monoxide and hydrogen.
- gases volatilized from the rich solvent together with stripping gas pass upwardly through vessel 13, thence through entrainment knock-out section 14, similar in construction to knock-out entrainment section 9, for the purpose of preventing droplets of liquid from being carried over into the gas, and the gas mixturepassing through entrainment knock-out section 14 containing hydrogen sulfide together with some carbon dioxide and stripping gas, as well as minor amounts of other constituents, discharges from the system through line 16.
- the gas containing hydrogen sulfide may be directed to aClaus plant for conversion of the hydrogen sulfide into elemental sulfur.
- rich solvent flowing from absorber 4 through line 7 is first subjected to flashing to remove some dissolved hydrocarbon gas, the flashing step may be omitted and the solvent flowing through line 7 may be directed directly to stripper 13 in which event the gases released from stripper 13 through line 16 willl. contain a small amount of hydrocarbon gas, which hydrocarbon gas may not be detrimental to'the operation of the Claus plant.' a
- Lean solvent from'the bottom of stripper l3 flows through line 17 and is forced by pump 18 through line 19 into conditioner 21 provided with packing or plates to facilitate contact between the liquid entering and gas introduced into the vessel 21.
- Gas from absorber 4 substantially'free of hydrogen sulfide passes up through entrainment knock-out section 22, thence through line 3 into expansion turbine 23 wherein the gas expands and drives the turbine thereby generating power and also during its expansion becomes colder as a result of the work being done and the J oule-Thompson effect.
- the amount of power generated by the expansion of the gas is several times that required to operate the plant. The surplus power can,
- the cooled gas from expansion turbine 23 flows through line 24 into conditioner 21 where it passes in intimate contact with the lean solvent entering through line 19. Direct contact of the cool gas entering through line 24with the lean solvent entering line 19 in conditioner 21 has a dual effect providing both carbon dioxide absorption in the solvent and cooling of the solvent to a temperature below the temperature in the absorption column 4.
- the pressure is generally about 200 to' 1,000 poundsper square inch lower than that of the absorber, preferably about 300 to 700 pounds lower.
- Solvent medium i.e., solvent substantially saturated with carbon dioxide and at a lower temperature, below that in absorber 4,. discharges from conditioner 21 through line Hand is forced by pump 26 through line 6 into the top of absorber 4 for scrubbing the incoming gases entering through line 5 to remove therefrom the hydrogen sulfide.
- Gases entering conditioner 21 EXAMPLE 1 In an operation as illustrated in the drawing, feed gas containing principally methane together. with carbon dioxide and hydrogen sulfide (the composition of the feed is shown in the tabulation which follows) at a pressure of 1,000 pounds per square inch absolute and a temperature of 120 F. is cooled to 94 F. by indirect heat exchange with gases leaving the absorption column.
- Solvent medium composed of a mixture of the normally liquid dimethylethers of polyethylene glycols containing 3 8 ethylene units and saturated with carbon dioxide is introduced at a temperature of 70 F.
- the gas from line 28 is substantially free of hydrogen sulfide, i.e., contains less than about 5 parts per million hydrogen sulfide and retains most of its original content of carbon dioxide and is suitable for conversion into synthesis gas for the production of methane.
- the flash tank is kept at about a half level, i.e., the flash tank is kept about half filled with liquid, and is retained in the flash tank for a residence time of approximately one minute.
- Lean solvent from the stripping column at a tempera ture of 91 F. is pumped into a conditioner chamber which is a vessel containing five trays. Gas from the top lean solvent thereby saturating the lean solvent with carbon dioxide gas and cooling the lean solvent to a temperature of 69 F.
- the product released from the. top of conditioner chamber maintained at a pressure of 425 pounds per square inch absolute consists primarily of methane together with most of the carbon dioxide in the feed gas but is reduced in hydrogen sulfide content to a value of 5 parts per million.
- the solvent medium from the conditioner is pumped at the rate of 9,400 gallons per minute and at a temperature of 70 F.
- the power generk. discharging the volatilized hydrogen sulfide from ated by the expansion turbine is 27,000 brake horsethe stripping zone; and power. 1 l. passing the lean solvent from the stripping zone to The composition of the feed and products and the the conditioning zone for cooling and solution of rate of flow per hour is'given in the tabulation below: 10 carbon dioxide to thus produce a solvent medium.
- a process for purification of a gas mixture contain- 25 solvent from the absorption zone is first sent to a flashing principally methane together with carbon dioxide ing zone to. liberate minor amounts of methane and and minoramounts of hydrogen sulfide to remove sub- CO dissolved in the rich solvent, and the thus denuded stantially all the hydrogen sulfide while retaining most solvent passed to the stripping zone for removal of hyof the carbon dioxide in the gas mixture which comdrogen sulfide.
- Aprocess as claimed inclaim 1 wherein the-solwith lean solvent in a conditioning zone to cool the v t i a ixtur f dimethyl ethers f polyethylen glysolvent to a temperature below the temperature of cols having 3 8 ethylene units. the absorption zone and to dissolve carbon dioxide 11.
- a process for purification of natural gas containin the lean solvent; ing principally methane together with carbon dioxide h.
- a process as claimed in claim 1 wherein the gas mixture to be purified is derived from fossil fuel.
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- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Analytical Chemistry (AREA)
- Organic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Health & Medical Sciences (AREA)
- Water Supply & Treatment (AREA)
- Biomedical Technology (AREA)
- Gas Separation By Absorption (AREA)
- Treating Waste Gases (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
- Industrial Gases (AREA)
Priority Applications (9)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US00359032A US3824766A (en) | 1973-05-10 | 1973-05-10 | Gas purification |
GB1759074A GB1464006A (en) | 1973-05-10 | 1974-04-22 | Gas purufication |
NLAANVRAGE7405563,A NL180202C (nl) | 1973-05-10 | 1974-04-25 | Werkwijze voor het reinigen van een gasmengsel, dat in hoofdzaak bestaat uit methaan, en kooldioxyde en waterstofsulfide bevat. |
DE2421956A DE2421956C2 (de) | 1973-05-10 | 1974-05-07 | Verfahren zur Entfernung von Schwefelwasserstoff aus einem Gasgemisch |
BE144104A BE814766A (fr) | 1973-05-10 | 1974-05-09 | Procede de purification de melanges gazeux contenant principalement du methane et nouveaux produits ainsi obtenus |
FR7416105A FR2228525B1 (fr) | 1973-05-10 | 1974-05-09 | |
CA199,424A CA1027336A (fr) | 1973-05-10 | 1974-05-09 | Purification des gaz |
JP5274574A JPS5653598B2 (fr) | 1973-05-10 | 1974-05-10 | |
IT68476/74A IT1020610B (it) | 1973-05-10 | 1974-05-10 | Purificazione di gas |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US00359032A US3824766A (en) | 1973-05-10 | 1973-05-10 | Gas purification |
Publications (1)
Publication Number | Publication Date |
---|---|
US3824766A true US3824766A (en) | 1974-07-23 |
Family
ID=23412030
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US00359032A Expired - Lifetime US3824766A (en) | 1973-05-10 | 1973-05-10 | Gas purification |
Country Status (9)
Country | Link |
---|---|
US (1) | US3824766A (fr) |
JP (1) | JPS5653598B2 (fr) |
BE (1) | BE814766A (fr) |
CA (1) | CA1027336A (fr) |
DE (1) | DE2421956C2 (fr) |
FR (1) | FR2228525B1 (fr) |
GB (1) | GB1464006A (fr) |
IT (1) | IT1020610B (fr) |
NL (1) | NL180202C (fr) |
Cited By (52)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3910777A (en) * | 1972-12-20 | 1975-10-07 | Linde Ag | Absorption system for separate recovery of carbon dioxide and hydrogen sulfide impurities |
US3977972A (en) * | 1975-04-02 | 1976-08-31 | Exxon Research And Engineering Company | Method and apparatus for reclaiming contaminated liquid |
US4097250A (en) * | 1976-03-05 | 1978-06-27 | Snamprogetti, S.P.A. | Method for the purification of natural gas having a high contents of acidic gases |
US4238206A (en) * | 1979-03-05 | 1980-12-09 | Columbia Gas System Service Corporation | Using solvents for acidic gas removal |
EP0033029A1 (fr) * | 1979-11-07 | 1981-08-05 | Air Products And Chemicals, Inc. | Procédé pour concentrer et éliminer de l'hydrogène sulfuré d'un mélange de gaz contaminé |
US4295864A (en) * | 1978-12-14 | 1981-10-20 | Metallgesellschaft Aktiengesellschaft | Process of treating pressurized condensate |
US4325782A (en) * | 1979-11-17 | 1982-04-20 | Metallgesellschaft Aktiengesellschaft | Apparatus for regenerating absorbent and method of operating the apparatus |
US4330305A (en) * | 1976-03-19 | 1982-05-18 | Basf Aktiengesellschaft | Removal of CO2 and/or H2 S from gases |
EP0052482A1 (fr) * | 1980-11-13 | 1982-05-26 | Air Products And Chemicals, Inc. | Procédé pour le traitement d'un courant de gaz industriels |
EP0062789A2 (fr) * | 1981-03-31 | 1982-10-20 | BASF Aktiengesellschaft | Procédé pour séparer des hydrocarbures aliphatiques condensables et des gaz acides de gaz naturel |
US4372925A (en) * | 1980-03-31 | 1983-02-08 | Shell Oil Company | Process for the removal of acid gases from gas mixtures containing methane |
US4451270A (en) * | 1982-06-30 | 1984-05-29 | Bend Research, Inc. | Absorption process for producing oxygen and nitrogen and solution therefor |
US4529413A (en) * | 1984-03-19 | 1985-07-16 | Phillips Petroleum Company | Recovering dessicant-antifreeze from admixture with water and hydrogen sulfide |
US4548620A (en) * | 1984-02-07 | 1985-10-22 | Key Engineering, Inc. | Process for treating natural gas |
US4552572A (en) * | 1983-07-26 | 1985-11-12 | Bechtel International Corporation | Process for desulfurization of fuel gas |
US4568364A (en) * | 1984-03-22 | 1986-02-04 | Bechtel International Corporation | Process for desulfurization of fuel gas |
US4589889A (en) * | 1983-03-31 | 1986-05-20 | Peter Spencer | Method and apparatus for the removal of noxious acidic gases from a hot exhaust gas stream |
US4741745A (en) * | 1986-05-07 | 1988-05-03 | Norton Company | Process for separation of carbon dioxide from other gases |
US4834781A (en) * | 1987-03-28 | 1989-05-30 | Metallgesellschaft Ag | Process for treating CO2 -containing absorbent solution |
US4957515A (en) * | 1988-11-03 | 1990-09-18 | Air Products And Chemicals, Inc. | Process for sulfur removal and recovery from fuel gas using physical solvent |
US4979966A (en) * | 1988-09-26 | 1990-12-25 | Institut Francais Du Petrole | Process and apparatus for the dehydration, deacidification, and separation of a condensate from a natural gas |
US5167675A (en) * | 1992-01-24 | 1992-12-01 | Process Equipment And Service Company, Inc. | Regeneration system for glycol dehydrator |
US5240476A (en) * | 1988-11-03 | 1993-08-31 | Air Products And Chemicals, Inc. | Process for sulfur removal and recovery from a power generation plant using physical solvent |
EP0707880A1 (fr) * | 1994-10-21 | 1996-04-24 | Metallgesellschaft Ag | Procédé de purification d'un gaz avec un liquide de lavage |
EP0744206A2 (fr) * | 1995-05-22 | 1996-11-27 | Hoechst Aktiengesellschaft | Procédé et dispositif pour purifier des gaz inertes |
US5582714A (en) * | 1995-03-20 | 1996-12-10 | Uop | Process for the removal of sulfur from petroleum fractions |
EP0770420A2 (fr) | 1995-10-23 | 1997-05-02 | Union Carbide Chemicals & Plastics Technology Corporation | Composition et méthode pour le traitement de gaz acides |
WO1997016505A1 (fr) * | 1995-11-03 | 1997-05-09 | Mcdermott Engineers & Constructors (Canada) Ltd. | Procede de recuperation de propane |
EP0848982A1 (fr) * | 1996-12-19 | 1998-06-24 | Institut Francais Du Petrole | Procédé et dispositif de traitement d'un gaz par refrigeration et mise en contact avec un solvant |
US6174348B1 (en) * | 1999-08-17 | 2001-01-16 | Praxair Technology, Inc. | Nitrogen system for regenerating chemical solvent |
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US6416568B1 (en) * | 1999-05-14 | 2002-07-09 | Texaco, Inc. | Hydrogen recycle and acid gas removal using a membrane |
US6642421B1 (en) | 2000-04-18 | 2003-11-04 | Exxonmobil Research And Engineering Company | Method for isolating enriched source of conducting polymers precursors |
US6641716B1 (en) | 2000-04-18 | 2003-11-04 | Exxonmobil Research And Engineering Company | Method for isolating enriched source of conducting polymers precursors using monohydroxyl alcohol treating agent |
US20040092774A1 (en) * | 2000-10-25 | 2004-05-13 | The Kansai Electric Power Co., Inc. | Amine recovery method and apparatus and decarbonatio apparatus having same |
WO2004052511A1 (fr) * | 2002-12-12 | 2004-06-24 | Fluor Corporation | Configurations et methodes d'elimination de gaz acides |
US6955705B1 (en) * | 2004-06-02 | 2005-10-18 | Rdc Research Llc | Method and system for compressing and dehydrating wet natural gas produced from low-pressure wells |
US20060185512A1 (en) * | 2003-03-21 | 2006-08-24 | Schubert Craig N | Improved composition and method for removal of carbonylsulfide from acid gas containing same |
US20080066618A1 (en) * | 2006-09-15 | 2008-03-20 | Olsen Andrew J | System and method for removing water and siloxanes from gas |
US20100280277A1 (en) * | 2007-09-26 | 2010-11-04 | Dow Global Technologies Inc. | Process for making ethers from alkoxide anions or precursors of alkoxide anions |
US20100278711A1 (en) * | 2007-10-12 | 2010-11-04 | Rasmus Find | Removal of carbon dioxide from a feed gas |
US20110067302A1 (en) * | 2009-09-24 | 2011-03-24 | General Electric Company | Carbon capture cooling system and method |
CN102661166A (zh) * | 2012-05-03 | 2012-09-12 | 河南理工大学 | 一种利用离子液体提纯矿井抽采瓦斯的方法 |
US20120297822A1 (en) * | 2010-02-02 | 2012-11-29 | Michael Edward Bailey | Separation of gases |
WO2013004335A1 (fr) * | 2011-07-01 | 2013-01-10 | Linde Aktiengesellschaft | Procedes et dispositifs pour obtenir des produits gazeux |
US20130139687A1 (en) * | 2011-12-06 | 2013-06-06 | Linde Aktiengesellschaft | Method for the removal of acid gases from a residual gas of an alcohol synthesis |
US8845788B2 (en) | 2011-08-08 | 2014-09-30 | Fluor Technologies Corporation | Methods and configurations for H2S concentration in acid gas removal |
WO2016209593A1 (fr) | 2015-06-26 | 2016-12-29 | Dow Global Technologies Llc | Composition de diméthyl éthylène glycol améliorée pour le traitement de gaz acides |
RU2630085C1 (ru) * | 2016-11-22 | 2017-09-05 | Андрей Владиславович Курочкин | Устройство для абсорбции кислых газов |
DE102016010314A1 (de) | 2016-08-25 | 2018-03-01 | Linde Aktiengesellschaft | Einsatz von Expansionsmaschinen in Gaswäschen |
WO2018068897A1 (fr) * | 2016-10-13 | 2018-04-19 | Linde Aktiengesellschaft | Procédé et installation pour purifier un gaz comprenant une unité de strippage fonctionnant à l'azote |
US20230183066A1 (en) * | 2021-12-15 | 2023-06-15 | Saudi Arabian Oil Company | Adsorption-based claus tail gas treatment |
Families Citing this family (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
FR2305413A1 (fr) * | 1975-03-24 | 1976-10-22 | Shell Int Research | Procede pour purifier un courant d'hydrocarbure gazeux contenant des gaz acides |
GB2035123B (en) * | 1978-11-23 | 1983-05-11 | Air Prod & Chem | Removing hydrogen sulphide from a gaseous mixtures comprising hydrogen sulphide and carbon dioxide |
GB2150855A (en) * | 1983-10-17 | 1985-07-10 | Humphreys & Glasgow Ltd | Acid gas removal with power recovery |
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US3362133A (en) * | 1965-10-25 | 1968-01-09 | Allied Chem | Process for hydrogen sulfide removal from gas mixtures containing h2s and co2 |
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1973
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- 1974-04-25 NL NLAANVRAGE7405563,A patent/NL180202C/xx not_active IP Right Cessation
- 1974-05-07 DE DE2421956A patent/DE2421956C2/de not_active Expired
- 1974-05-09 BE BE144104A patent/BE814766A/fr not_active IP Right Cessation
- 1974-05-09 CA CA199,424A patent/CA1027336A/fr not_active Expired
- 1974-05-09 FR FR7416105A patent/FR2228525B1/fr not_active Expired
- 1974-05-10 IT IT68476/74A patent/IT1020610B/it active
- 1974-05-10 JP JP5274574A patent/JPS5653598B2/ja not_active Expired
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US3531917A (en) * | 1966-10-14 | 1970-10-06 | Metallgesellschaft Ag | Process for a selective removal mainly of h2s and co2 by scrubbing from fuel and synthesis gases |
US3770622A (en) * | 1970-12-28 | 1973-11-06 | Fluor Corp | Treatment of wet natural gas mixtures to recover liquid hydrocarbons |
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US3910777A (en) * | 1972-12-20 | 1975-10-07 | Linde Ag | Absorption system for separate recovery of carbon dioxide and hydrogen sulfide impurities |
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US4097250A (en) * | 1976-03-05 | 1978-06-27 | Snamprogetti, S.P.A. | Method for the purification of natural gas having a high contents of acidic gases |
US4330305A (en) * | 1976-03-19 | 1982-05-18 | Basf Aktiengesellschaft | Removal of CO2 and/or H2 S from gases |
US4295864A (en) * | 1978-12-14 | 1981-10-20 | Metallgesellschaft Aktiengesellschaft | Process of treating pressurized condensate |
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EP0033029A1 (fr) * | 1979-11-07 | 1981-08-05 | Air Products And Chemicals, Inc. | Procédé pour concentrer et éliminer de l'hydrogène sulfuré d'un mélange de gaz contaminé |
US4325782A (en) * | 1979-11-17 | 1982-04-20 | Metallgesellschaft Aktiengesellschaft | Apparatus for regenerating absorbent and method of operating the apparatus |
US4372925A (en) * | 1980-03-31 | 1983-02-08 | Shell Oil Company | Process for the removal of acid gases from gas mixtures containing methane |
EP0052482A1 (fr) * | 1980-11-13 | 1982-05-26 | Air Products And Chemicals, Inc. | Procédé pour le traitement d'un courant de gaz industriels |
EP0062789A2 (fr) * | 1981-03-31 | 1982-10-20 | BASF Aktiengesellschaft | Procédé pour séparer des hydrocarbures aliphatiques condensables et des gaz acides de gaz naturel |
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US4414004A (en) * | 1981-03-31 | 1983-11-08 | Basf Aktiengesellschaft | Removal of condensable aliphatic hydrocarbons and acidic gases from natural gas |
USRE33352E (en) * | 1982-06-30 | 1990-09-25 | Bend Research, Inc. | Absorption process for producing oxygen and nitrogen and solution therefor |
US4451270A (en) * | 1982-06-30 | 1984-05-29 | Bend Research, Inc. | Absorption process for producing oxygen and nitrogen and solution therefor |
US4589889A (en) * | 1983-03-31 | 1986-05-20 | Peter Spencer | Method and apparatus for the removal of noxious acidic gases from a hot exhaust gas stream |
US4552572A (en) * | 1983-07-26 | 1985-11-12 | Bechtel International Corporation | Process for desulfurization of fuel gas |
US4548620A (en) * | 1984-02-07 | 1985-10-22 | Key Engineering, Inc. | Process for treating natural gas |
US4529413A (en) * | 1984-03-19 | 1985-07-16 | Phillips Petroleum Company | Recovering dessicant-antifreeze from admixture with water and hydrogen sulfide |
US4568364A (en) * | 1984-03-22 | 1986-02-04 | Bechtel International Corporation | Process for desulfurization of fuel gas |
US4741745A (en) * | 1986-05-07 | 1988-05-03 | Norton Company | Process for separation of carbon dioxide from other gases |
US4834781A (en) * | 1987-03-28 | 1989-05-30 | Metallgesellschaft Ag | Process for treating CO2 -containing absorbent solution |
US4979966A (en) * | 1988-09-26 | 1990-12-25 | Institut Francais Du Petrole | Process and apparatus for the dehydration, deacidification, and separation of a condensate from a natural gas |
US4957515A (en) * | 1988-11-03 | 1990-09-18 | Air Products And Chemicals, Inc. | Process for sulfur removal and recovery from fuel gas using physical solvent |
US5240476A (en) * | 1988-11-03 | 1993-08-31 | Air Products And Chemicals, Inc. | Process for sulfur removal and recovery from a power generation plant using physical solvent |
US5167675A (en) * | 1992-01-24 | 1992-12-01 | Process Equipment And Service Company, Inc. | Regeneration system for glycol dehydrator |
EP0707880A1 (fr) * | 1994-10-21 | 1996-04-24 | Metallgesellschaft Ag | Procédé de purification d'un gaz avec un liquide de lavage |
US5582714A (en) * | 1995-03-20 | 1996-12-10 | Uop | Process for the removal of sulfur from petroleum fractions |
EP0744206A3 (fr) * | 1995-05-22 | 1997-03-19 | Hoechst Ag | Procédé et dispositif pour purifier des gaz inertes |
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WO1997016505A1 (fr) * | 1995-11-03 | 1997-05-09 | Mcdermott Engineers & Constructors (Canada) Ltd. | Procede de recuperation de propane |
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Also Published As
Publication number | Publication date |
---|---|
DE2421956A1 (de) | 1974-11-28 |
FR2228525B1 (fr) | 1980-08-14 |
CA1027336A (fr) | 1978-03-07 |
BE814766A (fr) | 1974-09-02 |
NL180202C (nl) | 1987-01-16 |
JPS5035202A (fr) | 1975-04-03 |
NL7405563A (fr) | 1974-11-12 |
GB1464006A (en) | 1977-02-09 |
DE2421956C2 (de) | 1985-11-07 |
JPS5653598B2 (fr) | 1981-12-19 |
FR2228525A1 (fr) | 1974-12-06 |
IT1020610B (it) | 1977-12-30 |
NL180202B (nl) | 1986-08-18 |
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Legal Events
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Owner name: ALLIED CORPORATION Free format text: CHANGE OF NAME;ASSIGNOR:ALLIED CHEMICAL CORPORATION;REEL/FRAME:003996/0971 Effective date: 19810427 |
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Owner name: NORTON COMPANY, ONE NEW BOND ST. WORCESTER, MASS. Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:ALLIED CORPORATION;REEL/FRAME:003961/0409 Effective date: 19820326 |